This document provides a supplemental analysis of potential costs and benefits to the City of Hermosa Beach if a proposed oil drilling and recovery project is approved. It analyzes provisions of a development agreement negotiated between the City and the project applicant. Key findings include:
1) Under the development agreement terms, the City could realize $138-301 million over 35 years from royalties, with $46-109 million for the general fund. This is higher than the $118-270 million and $25-77 million estimated without the agreement.
2) The development agreement provides benefits like accelerated royalty payments, bonus payments ensuring $1 million minimum royalties, maintenance yard remediation and relocation, and payments
energy future holindings TCEHHoldingsQuarterlyFinancialsProFormasfinance29
This document provides unaudited pro forma condensed consolidated financial statements for Texas Competitive Electric Holdings Company LLC (TCEH) that give effect to TCEH's merger with EFH Corp. and related financing transactions. The pro forma adjustments include:
1) Allocating the estimated purchase price from the merger to reflect the fair values of TCEH's assets and liabilities.
2) Adjusting for the impact of debt issued and retired to complete the merger.
3) Reflecting the historical results of certain assets contributed by EFH Corp. to TCEH.
The financial statements are intended to provide information on the estimated financial effects of the merger and are not indicative of TCEH
Dairy Resource List: Organic and Pasture-BasedGardening
This document provides an annotated list of resources for organic and pasture-based dairy farmers. It lists print and online sources that cover topics like organic dairying overviews, grazing management, soil health, animal management, marketing, finances, research organizations, and transitioning to organic certification. The resources include books, publications, websites, and organizations that can help farmers seeking information on organic and pasture-based dairy production.
This document provides information about amaranth production, including that amaranth is a grain crop that can be popped, flaked, or ground into flour. It is well-adapted to the midwestern and western US. The document discusses organizations that support amaranth production and research, such as the Amaranth Institute and Jefferson Institute. It also provides references for further resources on amaranth production, marketing, and seed sources.
1) El documento describe aspectos de arquitectura de software como la complejidad inherente a los sistemas y la necesidad de descomponerlos para hacerlos más manejables. 2) También discute cómo la arquitectura debe hacer que el desarrollo y gestión de los sistemas sea más fácil al proveer abstracciones y conceptos unificadores. 3) Finalmente, explica que la arquitectura debe considerar el comportamiento dinámico del sistema y el soporte necesario para sus funcionalidades.
The Meditech MD200 is a low-power oxygen monitor module that uses an advanced DSP algorithm to measure blood oxygen saturation and pulse rate accurately, even during motion or low perfusion. It is small in size and easy to assemble. The module communicates data like oxygen saturation, pulse rate, and plethysmogram readings to a host device via an asynchronous serial port. It has a wide operating temperature and altitude range and is compatible with infant, newborn, and adult probes.
Este documento presenta un resumen de 3 oraciones o menos de los siguientes puntos clave del documento proporcionado:
1. Explica brevemente diferentes métodos o modelos de procesos de desarrollo de software como el proceso en cascada, el modelo en V, el proceso en espiral y los procesos iterativos e incrementales.
2. Define conceptos clave como roles, hitos, ciclo de vida y procesos.
3. Discuten brevemente las limitaciones del proceso en cascada y por qué es importante aplicar un método de
Companion planting involves growing two or more plant species in close proximity to provide cultural benefits like pest control or higher yields. While traditionally based on observation, scientific research has validated mechanisms like trap cropping, nitrogen fixation, biochemical pest suppression, and providing habitat for beneficial insects. A companion planting chart lists traditional associations and incompatibilities for common garden crops. Intercropping systems range from mixed to strip planting arrangements.
This document discusses considerations for organic hog production. It covers the natural behaviors of hogs like nesting and farrowing, rooting, wallowing, and foraging. It also discusses housing options that allow animals to express natural behaviors like pasture farrowing and finishing systems. The document provides an overview of the USDA organic livestock standards regarding space, access to outdoors, shelter design and temporary confinement. It also discusses husbandry practices to reduce stress during handling, weaning and physical alterations.
energy future holindings TCEHHoldingsQuarterlyFinancialsProFormasfinance29
This document provides unaudited pro forma condensed consolidated financial statements for Texas Competitive Electric Holdings Company LLC (TCEH) that give effect to TCEH's merger with EFH Corp. and related financing transactions. The pro forma adjustments include:
1) Allocating the estimated purchase price from the merger to reflect the fair values of TCEH's assets and liabilities.
2) Adjusting for the impact of debt issued and retired to complete the merger.
3) Reflecting the historical results of certain assets contributed by EFH Corp. to TCEH.
The financial statements are intended to provide information on the estimated financial effects of the merger and are not indicative of TCEH
Dairy Resource List: Organic and Pasture-BasedGardening
This document provides an annotated list of resources for organic and pasture-based dairy farmers. It lists print and online sources that cover topics like organic dairying overviews, grazing management, soil health, animal management, marketing, finances, research organizations, and transitioning to organic certification. The resources include books, publications, websites, and organizations that can help farmers seeking information on organic and pasture-based dairy production.
This document provides information about amaranth production, including that amaranth is a grain crop that can be popped, flaked, or ground into flour. It is well-adapted to the midwestern and western US. The document discusses organizations that support amaranth production and research, such as the Amaranth Institute and Jefferson Institute. It also provides references for further resources on amaranth production, marketing, and seed sources.
1) El documento describe aspectos de arquitectura de software como la complejidad inherente a los sistemas y la necesidad de descomponerlos para hacerlos más manejables. 2) También discute cómo la arquitectura debe hacer que el desarrollo y gestión de los sistemas sea más fácil al proveer abstracciones y conceptos unificadores. 3) Finalmente, explica que la arquitectura debe considerar el comportamiento dinámico del sistema y el soporte necesario para sus funcionalidades.
The Meditech MD200 is a low-power oxygen monitor module that uses an advanced DSP algorithm to measure blood oxygen saturation and pulse rate accurately, even during motion or low perfusion. It is small in size and easy to assemble. The module communicates data like oxygen saturation, pulse rate, and plethysmogram readings to a host device via an asynchronous serial port. It has a wide operating temperature and altitude range and is compatible with infant, newborn, and adult probes.
Este documento presenta un resumen de 3 oraciones o menos de los siguientes puntos clave del documento proporcionado:
1. Explica brevemente diferentes métodos o modelos de procesos de desarrollo de software como el proceso en cascada, el modelo en V, el proceso en espiral y los procesos iterativos e incrementales.
2. Define conceptos clave como roles, hitos, ciclo de vida y procesos.
3. Discuten brevemente las limitaciones del proceso en cascada y por qué es importante aplicar un método de
Companion planting involves growing two or more plant species in close proximity to provide cultural benefits like pest control or higher yields. While traditionally based on observation, scientific research has validated mechanisms like trap cropping, nitrogen fixation, biochemical pest suppression, and providing habitat for beneficial insects. A companion planting chart lists traditional associations and incompatibilities for common garden crops. Intercropping systems range from mixed to strip planting arrangements.
This document discusses considerations for organic hog production. It covers the natural behaviors of hogs like nesting and farrowing, rooting, wallowing, and foraging. It also discusses housing options that allow animals to express natural behaviors like pasture farrowing and finishing systems. The document provides an overview of the USDA organic livestock standards regarding space, access to outdoors, shelter design and temporary confinement. It also discusses husbandry practices to reduce stress during handling, weaning and physical alterations.
Colorado Potato Beetle: Organic Control OptionsGardening
This document provides information on organic control options for the Colorado potato beetle (CPB), a major pest of potatoes. It summarizes several cultural, physical and biological control strategies including crop rotation, flaming, row covers, traps, mulching and varietal resistance. It also discusses the use of natural enemies, botanical insecticides like neem and pyrethrum, and biopesticides including Bacillus thuringiensis and Beauveria bassiana for managing CPB populations organically.
Protecting Water Quality on Organic FarmsGardening
This document summarizes how organic farms can protect water quality through various farming practices that mimic natural systems. It discusses how organic farms tend to have less nitrogen leaching, better nutrient retention, more efficient nutrient cycling, and less runoff/erosion compared to conventional farms. However, it also notes that without proper management, organic practices can still cause environmental issues. The document then outlines specific organic practices that protect water quality, such as increasing soil organic matter, using cover crops, composting manure, crop rotations, and conservation practices. It provides guidelines for organic farmers to implement these practices and modify their management to suit their conditions and protect water resources.
This document provides an overview and guide to publications from ATTRA (Appropriate Technology Transfer for Rural Areas) related to organic agriculture. It describes the types of publications available, including those on organic rule and compliance, farm inputs, marketing and business, horticultural crops, field crops, livestock, soils and compost, and pest management. It provides the titles and brief descriptions of over 30 individual publications that cover topics such as organic certification, standards for crop and livestock production, marketing resources, and production guides for various organic crops. The guide aims to help users learn about and access ATTRA's information on organic farming practices and certification requirements.
Edamame is the Japanese name for green vegetable soybeans. It is a traditional food popular in Asia that is becoming more popular in the United States. Edamame production is similar to traditional soybean production but requires larger seed sizes. It is harvested earlier when the pods and beans are still green and immature. Edamame can be marketed as whole plants, pods only, or shelled beans. Production costs are highest for harvesting and handling, and markets need to prioritize freshness for sales within 200 miles.
The document discusses three basic steps for organic producers and handlers to ensure compliant use of materials under the USDA's National Organic Program:
1. Understand the relevant NOP regulations by reviewing the full standards and identifying sections that address allowed and prohibited materials for your type of operation.
2. Create an Organic System Plan listing all materials to be used and obtain approval from your certifier before using any materials.
3. Document all material purchases and applications, and retain records for at least five years.
Following these three steps helps operations use materials correctly according to the standards and avoids issues that could require restarting the three-year transition to organic certification.
Har 1014 Vortec DBW Wiring Harness Manual and Instructions PSI Conversion
www.psiconversion.com
EFI Conversion Kits
Electronic Fuel Injection Wiring Harness Manual
Thank you for purchasing what PSI has designed as the most up-to-date and easiest to install automotive
fuel injection harness on the market. This harness is designed to be a complete wiring harness for the fuel
injection system on General Motors 2003 and newer Vortec fuel injected engines with Drive By Wire
Throttle Body and 4L60E or 4L80E transmission.
This harness is constructed with GM Delphi Connectors and Terminals with GXL/TXL (600 volt
polyethylene cross-linked) wire which is professionally assembled and 100% quality inspected prior to
shipping. This harness includes all wiring that is needed by the PCM to run and control the fuel injection
system and transmission
Tools for Managing Internal Parasites in Small Ruminants: Copper Wire ParticlesGardening
The document discusses copper oxide wire particles (COWP) as a tool for managing internal parasites in small ruminants like sheep and goats. It notes that overuse of dewormers has led to resistance, making them ineffective. COWP are described as a potentially effective alternative as they have been shown to reduce parasite loads. The document outlines how COWP can be administered by repackaging cattle boluses into smaller doses for sheep and goats using gel capsules. It also reviews several research studies that found COWP reduced fecal egg counts and the number of Haemonchus contortus parasites detected. However, it cautions that COWP should be one part of an integrated parasite management strategy.
This document provides information on producing wheatgrass through two methods: the bed method and field method. The bed method involves growing seeds in shallow beds of soil and peat moss or vermiculite, while the field method involves growing the grass longer in soil. Proper sanitation, storage, and liability insurance are important due to food safety risks. The document also discusses marketing wheatgrass and lists resources for further information.
Organic Standards for Crop Production: Highlights of the USDA's National Orga...Gardening
This document provides excerpts from the USDA's National Organic Program regulations regarding standards for organic crop production. It includes standards for all certified organic operations, crop production specific standards for land requirements, soil fertility and nutrient management, seeds and planting stock, crop rotation, pest and disease management, and wild crop harvesting. Lists of synthetic substances allowed and non-synthetic substances prohibited for use in organic crop production are also provided. The introduction explains that this is not a complete summary of all standards and should be used together with other relevant organic standards documents.
Cucumber Beetles: Organic and Biorational Integrated Pest ManagementGardening
This document provides information on organic and biorational integrated pest management strategies for controlling cucumber beetles, a major pest of cucurbit crops. It begins by describing the six species of cucumber beetles found in the US and their life cycles. It then discusses the damage caused by cucumber beetles and organic control methods including cultural practices, trap crops, predators/parasites, and botanical/biorational insecticides. The document emphasizes using a combination of these methods within an integrated pest management approach to control cucumber beetles organically.
This document provides an overview of organic grain, oilseed, and pulse markets. It discusses various food grains like wheat, corn, and oats as well as oilseeds like soybeans and pulses. Organic grain prices are typically double conventional prices. Demand is growing for organic foods, but supply and prices can be volatile depending on the crop. Successful organic grain marketing requires building relationships with buyers, contracting crops in advance, meeting quality standards, and having adequate storage facilities. Overall storage and relationships are key to getting premium prices in these markets.
The document summarizes information about raising dairy beef cattle. It discusses producing dairy beef calves on pasture, finishing cattle through grazing or combining grazing with grain feeding, and marketing dairy beef through niche markets. Key points include that dairy beef production can boost farm income, calves should receive adequate colostrum and milk replacer when young, and pasture finishing is possible but requires close grazing management.
Dung Beetle Benefits in the Pasture EcosystemGardening
This document summarizes information about dung beetles and their benefits in pasture ecosystems. It discusses the different types of dung beetles, their life cycles, behaviors, and importance in manure recycling and soil health. Specifically, it notes that dung beetles improve nutrient cycling, soil structure, forage growth, and help reduce pest populations like horn flies. The document also covers research on importing new dung beetle species to support pasture ecosystems and provides tips for management practices to encourage dung beetle populations.
This document provides energy saving tips for irrigators. It discusses recommended irrigation system installations, how utilities charge for electricity used for irrigation, common causes of wasted energy, and hardware improvements that can save energy. Specifically, it recommends installing pumps, motors, pipes and valves in a way that minimizes friction losses to increase efficiency. It also explains that utilities typically charge irrigators a base rate, an energy charge based on kilowatt-hours used, and sometimes a demand charge based on the system's maximum power usage. Common sources of wasted energy include a lack of maintenance allowing issues like plugged screens or worn parts, running pumps longer than needed to water crops, and using improperly sized equipment.
Martin Engineering has opened a new research center called the Center for Bulk Materials Handling Innovation (CFI) to improve understanding of bulk materials behavior and handling equipment performance through collaboration with industry partners. The $5 million facility houses scientists, engineers and testing equipment including a three-part recirculating conveyor system. CFI aims to advance knowledge of bulk materials and develop new handling technologies through applied research. Martin also offers educational programs and field services to help customers solve bulk material handling problems and improve plant operations.
This document provides an overview of organic sweet corn production, including key aspects such as varieties, soil fertility, crop rotations, weed control, insect pest management, diseases, harvesting, postharvest handling, marketing and economics. It discusses organic farming practices like using crop rotations, cover crops, compost and organic fertilizers to build soil fertility and manage pests without synthetic pesticides. The document also provides resources for further information on organic sweet corn production.
Building a Montana Organic Livestock IndustryGardening
The document summarizes a report on the costs of organic grass-finished beef production for members of the Montana Organic Producers Cooperative (MOPC). Key findings from the report include:
1. A survey of 18 MOPC members found wide variation in costs, including land values, machinery costs, labor hours, and grass productivity. Average total costs per acre of grass production were $71.76 but ranged from $5.46 to $207.03.
2. Fixed costs per acre averaged $35.36 while variable costs averaged $35.82. The average price needed to be profitable for members was $1.38 per pound of live weight.
3. Most members
This document provides guidance on creating a culture of success in an organization. It discusses that creating culture is difficult due to a lack of trust, fear of conflict, lack of commitment, avoidance of accountability, and inattention to results. It recommends leading with a clear purpose that attracts motivated people, being a leader with emotional intelligence, creating change through establishing urgency and empowering others, and ensuring messages are positive and celebrate successes rather than complain. The overall message is that strong, purpose-driven leadership and a focus on people are keys to developing a successful organizational culture.
- The company reported third quarter 2015 results with record production of 16.6 MBoe/d, up 17% year-over-year.
- Operating costs continued to decrease, with lease operating expenses of $5.04/Boe, a 14% reduction from the prior year.
- The company drilled 4 wells and completed 5 wells in the Wolfcamp B-C zones, with initial production averaging 931 Boe/d.
- The company reported results for the second quarter of 2015, with production increasing 8% year-over-year to 15.3 MBoe/d and cash operating costs decreasing 26% to $11.02/Boe.
- The company drilled 9 and completed 10 Wolfcamp wells in the quarter and continued reducing well costs, with an average of $4.5 million per well compared to $5.5 million in 2014.
- Financial highlights included $32.6 million in EBITDAX, capital expenditures of $56.9 million (mostly for drilling and completions), and liquidity of $193 million as of June 30th.
The document provides an overview of the company's fourth quarter and full-year 2015 results. Some key points:
- Production for Q4 was 1.33 MMBoe and 5.53 MMBoe for the full year, in line with guidance. No capital expenditures were incurred in Q4 due to low commodity prices.
- Proved reserves increased 14% year-over-year to 166.6 MMBoe with a PV-10 of $504 million. Drilling replaced 603% of production at a drill-bit F&D cost of $4.32/Boe.
- The company has $177 million in liquidity and reduced total debt from $515.6 million to $
Colorado Potato Beetle: Organic Control OptionsGardening
This document provides information on organic control options for the Colorado potato beetle (CPB), a major pest of potatoes. It summarizes several cultural, physical and biological control strategies including crop rotation, flaming, row covers, traps, mulching and varietal resistance. It also discusses the use of natural enemies, botanical insecticides like neem and pyrethrum, and biopesticides including Bacillus thuringiensis and Beauveria bassiana for managing CPB populations organically.
Protecting Water Quality on Organic FarmsGardening
This document summarizes how organic farms can protect water quality through various farming practices that mimic natural systems. It discusses how organic farms tend to have less nitrogen leaching, better nutrient retention, more efficient nutrient cycling, and less runoff/erosion compared to conventional farms. However, it also notes that without proper management, organic practices can still cause environmental issues. The document then outlines specific organic practices that protect water quality, such as increasing soil organic matter, using cover crops, composting manure, crop rotations, and conservation practices. It provides guidelines for organic farmers to implement these practices and modify their management to suit their conditions and protect water resources.
This document provides an overview and guide to publications from ATTRA (Appropriate Technology Transfer for Rural Areas) related to organic agriculture. It describes the types of publications available, including those on organic rule and compliance, farm inputs, marketing and business, horticultural crops, field crops, livestock, soils and compost, and pest management. It provides the titles and brief descriptions of over 30 individual publications that cover topics such as organic certification, standards for crop and livestock production, marketing resources, and production guides for various organic crops. The guide aims to help users learn about and access ATTRA's information on organic farming practices and certification requirements.
Edamame is the Japanese name for green vegetable soybeans. It is a traditional food popular in Asia that is becoming more popular in the United States. Edamame production is similar to traditional soybean production but requires larger seed sizes. It is harvested earlier when the pods and beans are still green and immature. Edamame can be marketed as whole plants, pods only, or shelled beans. Production costs are highest for harvesting and handling, and markets need to prioritize freshness for sales within 200 miles.
The document discusses three basic steps for organic producers and handlers to ensure compliant use of materials under the USDA's National Organic Program:
1. Understand the relevant NOP regulations by reviewing the full standards and identifying sections that address allowed and prohibited materials for your type of operation.
2. Create an Organic System Plan listing all materials to be used and obtain approval from your certifier before using any materials.
3. Document all material purchases and applications, and retain records for at least five years.
Following these three steps helps operations use materials correctly according to the standards and avoids issues that could require restarting the three-year transition to organic certification.
Har 1014 Vortec DBW Wiring Harness Manual and Instructions PSI Conversion
www.psiconversion.com
EFI Conversion Kits
Electronic Fuel Injection Wiring Harness Manual
Thank you for purchasing what PSI has designed as the most up-to-date and easiest to install automotive
fuel injection harness on the market. This harness is designed to be a complete wiring harness for the fuel
injection system on General Motors 2003 and newer Vortec fuel injected engines with Drive By Wire
Throttle Body and 4L60E or 4L80E transmission.
This harness is constructed with GM Delphi Connectors and Terminals with GXL/TXL (600 volt
polyethylene cross-linked) wire which is professionally assembled and 100% quality inspected prior to
shipping. This harness includes all wiring that is needed by the PCM to run and control the fuel injection
system and transmission
Tools for Managing Internal Parasites in Small Ruminants: Copper Wire ParticlesGardening
The document discusses copper oxide wire particles (COWP) as a tool for managing internal parasites in small ruminants like sheep and goats. It notes that overuse of dewormers has led to resistance, making them ineffective. COWP are described as a potentially effective alternative as they have been shown to reduce parasite loads. The document outlines how COWP can be administered by repackaging cattle boluses into smaller doses for sheep and goats using gel capsules. It also reviews several research studies that found COWP reduced fecal egg counts and the number of Haemonchus contortus parasites detected. However, it cautions that COWP should be one part of an integrated parasite management strategy.
This document provides information on producing wheatgrass through two methods: the bed method and field method. The bed method involves growing seeds in shallow beds of soil and peat moss or vermiculite, while the field method involves growing the grass longer in soil. Proper sanitation, storage, and liability insurance are important due to food safety risks. The document also discusses marketing wheatgrass and lists resources for further information.
Organic Standards for Crop Production: Highlights of the USDA's National Orga...Gardening
This document provides excerpts from the USDA's National Organic Program regulations regarding standards for organic crop production. It includes standards for all certified organic operations, crop production specific standards for land requirements, soil fertility and nutrient management, seeds and planting stock, crop rotation, pest and disease management, and wild crop harvesting. Lists of synthetic substances allowed and non-synthetic substances prohibited for use in organic crop production are also provided. The introduction explains that this is not a complete summary of all standards and should be used together with other relevant organic standards documents.
Cucumber Beetles: Organic and Biorational Integrated Pest ManagementGardening
This document provides information on organic and biorational integrated pest management strategies for controlling cucumber beetles, a major pest of cucurbit crops. It begins by describing the six species of cucumber beetles found in the US and their life cycles. It then discusses the damage caused by cucumber beetles and organic control methods including cultural practices, trap crops, predators/parasites, and botanical/biorational insecticides. The document emphasizes using a combination of these methods within an integrated pest management approach to control cucumber beetles organically.
This document provides an overview of organic grain, oilseed, and pulse markets. It discusses various food grains like wheat, corn, and oats as well as oilseeds like soybeans and pulses. Organic grain prices are typically double conventional prices. Demand is growing for organic foods, but supply and prices can be volatile depending on the crop. Successful organic grain marketing requires building relationships with buyers, contracting crops in advance, meeting quality standards, and having adequate storage facilities. Overall storage and relationships are key to getting premium prices in these markets.
The document summarizes information about raising dairy beef cattle. It discusses producing dairy beef calves on pasture, finishing cattle through grazing or combining grazing with grain feeding, and marketing dairy beef through niche markets. Key points include that dairy beef production can boost farm income, calves should receive adequate colostrum and milk replacer when young, and pasture finishing is possible but requires close grazing management.
Dung Beetle Benefits in the Pasture EcosystemGardening
This document summarizes information about dung beetles and their benefits in pasture ecosystems. It discusses the different types of dung beetles, their life cycles, behaviors, and importance in manure recycling and soil health. Specifically, it notes that dung beetles improve nutrient cycling, soil structure, forage growth, and help reduce pest populations like horn flies. The document also covers research on importing new dung beetle species to support pasture ecosystems and provides tips for management practices to encourage dung beetle populations.
This document provides energy saving tips for irrigators. It discusses recommended irrigation system installations, how utilities charge for electricity used for irrigation, common causes of wasted energy, and hardware improvements that can save energy. Specifically, it recommends installing pumps, motors, pipes and valves in a way that minimizes friction losses to increase efficiency. It also explains that utilities typically charge irrigators a base rate, an energy charge based on kilowatt-hours used, and sometimes a demand charge based on the system's maximum power usage. Common sources of wasted energy include a lack of maintenance allowing issues like plugged screens or worn parts, running pumps longer than needed to water crops, and using improperly sized equipment.
Martin Engineering has opened a new research center called the Center for Bulk Materials Handling Innovation (CFI) to improve understanding of bulk materials behavior and handling equipment performance through collaboration with industry partners. The $5 million facility houses scientists, engineers and testing equipment including a three-part recirculating conveyor system. CFI aims to advance knowledge of bulk materials and develop new handling technologies through applied research. Martin also offers educational programs and field services to help customers solve bulk material handling problems and improve plant operations.
This document provides an overview of organic sweet corn production, including key aspects such as varieties, soil fertility, crop rotations, weed control, insect pest management, diseases, harvesting, postharvest handling, marketing and economics. It discusses organic farming practices like using crop rotations, cover crops, compost and organic fertilizers to build soil fertility and manage pests without synthetic pesticides. The document also provides resources for further information on organic sweet corn production.
Building a Montana Organic Livestock IndustryGardening
The document summarizes a report on the costs of organic grass-finished beef production for members of the Montana Organic Producers Cooperative (MOPC). Key findings from the report include:
1. A survey of 18 MOPC members found wide variation in costs, including land values, machinery costs, labor hours, and grass productivity. Average total costs per acre of grass production were $71.76 but ranged from $5.46 to $207.03.
2. Fixed costs per acre averaged $35.36 while variable costs averaged $35.82. The average price needed to be profitable for members was $1.38 per pound of live weight.
3. Most members
This document provides guidance on creating a culture of success in an organization. It discusses that creating culture is difficult due to a lack of trust, fear of conflict, lack of commitment, avoidance of accountability, and inattention to results. It recommends leading with a clear purpose that attracts motivated people, being a leader with emotional intelligence, creating change through establishing urgency and empowering others, and ensuring messages are positive and celebrate successes rather than complain. The overall message is that strong, purpose-driven leadership and a focus on people are keys to developing a successful organizational culture.
- The company reported third quarter 2015 results with record production of 16.6 MBoe/d, up 17% year-over-year.
- Operating costs continued to decrease, with lease operating expenses of $5.04/Boe, a 14% reduction from the prior year.
- The company drilled 4 wells and completed 5 wells in the Wolfcamp B-C zones, with initial production averaging 931 Boe/d.
- The company reported results for the second quarter of 2015, with production increasing 8% year-over-year to 15.3 MBoe/d and cash operating costs decreasing 26% to $11.02/Boe.
- The company drilled 9 and completed 10 Wolfcamp wells in the quarter and continued reducing well costs, with an average of $4.5 million per well compared to $5.5 million in 2014.
- Financial highlights included $32.6 million in EBITDAX, capital expenditures of $56.9 million (mostly for drilling and completions), and liquidity of $193 million as of June 30th.
The document provides an overview of the company's fourth quarter and full-year 2015 results. Some key points:
- Production for Q4 was 1.33 MMBoe and 5.53 MMBoe for the full year, in line with guidance. No capital expenditures were incurred in Q4 due to low commodity prices.
- Proved reserves increased 14% year-over-year to 166.6 MMBoe with a PV-10 of $504 million. Drilling replaced 603% of production at a drill-bit F&D cost of $4.32/Boe.
- The company has $177 million in liquidity and reduced total debt from $515.6 million to $
- The document provides an overview of Antero Resources Corporation, a company focused on developing natural gas and oil resources from the Marcellus and Utica Shales.
- Antero has significant reserves and acreage positions in the Marcellus and Utica Shales, with over 37 trillion cubic feet of reserves across both plays.
- The company has invested heavily in midstream infrastructure like gathering lines and processing facilities to support its production and growth.
- Antero has also secured long-term firm transportation and processing agreements to achieve premium realized prices for its natural gas and natural gas liquids.
Company website presentation (b) november 2015AnteroResources
This document provides an overview of Antero Resources Corporation. It contains forward-looking statements regarding Antero's estimates, plans, strategies, objectives, expected financial and operating results. These statements are based on certain assumptions and are subject to risks and uncertainties. It also cautions readers that these forward-looking statements are subject to risks that could cause actual results to differ materially from expectations. The document provides updated information on Antero's reserves, production, well economics, acreage position, and drilling program as of September 30, 2015. It highlights Antero's leading position in the low-cost Marcellus and Utica shale plays with a large inventory of high-return drilling locations.
The document provides an overview of Antero Resources Corporation and contains forward-looking statements regarding estimates, plans, strategies, objectives, anticipated financial and operating results, and risks. It notes that actual results may differ materially from forward-looking statements due to assumptions, risks, and uncertainties. The document was updated since July 2015 to reflect changes in natural gas realizations, debt positions, growth rates, and capitalization as of June 30, 2015.
The document provides an overview of Antero Resources Corporation. It contains forward-looking statements regarding estimates, plans, strategies, objectives, anticipated financial and operating results, and risks. These statements are based on certain assumptions and are subject to known and unknown risks and uncertainties. The company cautions that forward-looking statements are subject to risks and uncertainties that could cause actual results to differ from expectations. The document was updated since October 2015 to reflect changes in leverage, liquidity, natural gas and equivalent realizations, debt position, and EBITDAX reconciliation as of September 30, 2015.
The document provides an overview of Antero Resources Corporation. It contains forward-looking statements regarding estimates, plans, strategies, objectives, anticipated financial and operating results, and other expectations. These statements are based on certain assumptions and are subject to risks and uncertainties. It cautions readers that actual results could differ materially from forward-looking statements. The company has updated certain slides since its prior presentation in October 2015 to reflect changes in pricing, liquidity, debt position, and other financial and operating statistics as of September 30, 2015.
The document provides an overview of Antero Resources Corporation. It contains forward-looking statements regarding estimates, plans, strategies, objectives, anticipated financial and operating results, and risks. These statements are based on certain assumptions made by the company. Actual results may differ materially from forward-looking statements due to risks and uncertainties including commodity price volatility and lack of availability of drilling equipment. The company has over 4,200 undrilled locations that are expected to have returns exceeding the company's weighted average cost of capital under current strip pricing. Antero is the most active driller in the Appalachian basin with over 1 million net acres and over 5,300 undrilled locations as of year-end 2014.
1) SandRidge Energy presented at the Howard Weil Energy Conference on March 24, 2015. The presentation provided an overview of the company, its assets and operations, capital expenditure plans for 2015, and strategies for adapting to lower oil prices.
2) Key points included outlining a $700 million capital expenditure budget for 2015, a plan to reduce the rig count from 19 to 7 rigs, and targeting $200 million in proceeds from asset sales. The presentation also highlighted efficiency gains and expanded use of multilaterals to reduce well costs.
3) SandRidge demonstrated success in 2014 by growing reserves 37% and type curves 27%, with 47% production growth in the Midcontinent. The presentation emphasized preserving value
Company website presentation (c) october 2014AnteroResources
- Antero Resources is a pure play company focused on developing natural gas and oil resources in the Marcellus and Utica Shales.
- As of June 30, 2014, Antero reported net proved reserves of 9.1 Tcfe and net 3P reserves of 37.5 Tcfe across its acreage positions.
- Antero has invested over $1.6 billion in midstream infrastructure including gathering lines, compressor stations, and fresh water distribution systems to support its production and operations.
Company website presentation (c) october 2014AnteroResources
- The company overview document discusses Antero Resources, a natural gas exploration and production company focused on the Marcellus and Utica Shale plays.
- Antero has significant reserves of 37.5 trillion cubic feet of gas equivalents across its acreage, along with high growth production that increased 91% year-over-year in the third quarter of 2014.
- The company has invested heavily in midstream infrastructure like processing plants and pipelines to efficiently develop its production and access favorable gas markets.
- The document provides financial and operational highlights for Arex Energy's fourth quarter and full-year 2014 results.
- Key highlights include record revenues and net income for the full year, strong production and reserve growth, capital expenditures below budget, and a flexible capital program for 2015 focused on financial discipline and returns.
- Operational results demonstrated continued strong well performance and recoveries from the Wolfcamp shale play, Arex's core asset.
Company website presentation (a) november 2014AnteroResources
This document provides an overview of Antero Resources Corporation. It discusses Antero's position as a pure play company focused on the Marcellus and Utica Shales, with over 37 Tcfe of reserves across the regions. Antero plans significant growth through its 22-rig drilling program across the plays. The company has leading capital efficiency and strong liquidity and hedge positions to support its high growth strategy. Antero is building substantial firm processing and takeaway capacity by 2018 to access favorable gas markets.
Company website presentation (a) november 2014(2)AnteroResources
This document provides an overview of Antero Resources Corporation. It states that Antero has significant reserves and acreage in the Marcellus and Utica Shales, with plans for continued production and liquids growth. Antero aims to be the lowest cost producer through capital efficiency and industry-leading well economics. It has secured substantial firm transportation and processing commitments to access favorable gas markets.
The document provides an overview of Antero Resources Corporation, including:
- Antero has significant reserves of 37.5 Tcfe primarily in the Marcellus and Utica shale plays with strong production growth.
- The company has industry-leading capital efficiency and a top quartile return on productive capital.
- Antero has significant midstream infrastructure and secured firm transportation for its gas and NGL production.
The document provides an overview of Antero Resources Corporation, including:
- Antero has significant reserves of 37.5 Tcfe primarily in the Marcellus and Utica shale plays with strong production growth.
- The company has industry-leading capital efficiency and a top quartile return on productive capital, with low development costs and a high growth-adjusted recycle ratio.
- Antero has invested heavily in midstream infrastructure like processing plants and pipelines to support its production and has secured significant firm transportation contracts.
The document provides an overview of a partnership between Antero Midstream Partners LP and Antero Resources Corporation. Key details include a $1.05 billion initial payment for Antero's water delivery business and 20-year agreement for fluid handling and disposal services. Minimum volume commitments are expected to support revenues. Earn out payments over the next few years provide incentives for Antero to meet long-term volume targets. The partnership is expected to be accretive and integrate Antero's water and gathering businesses to create one of the highest growth midstream MLPs.
- Antero Resources is a pure play company focused on developing natural gas and oil resources in the Marcellus and Utica Shales.
- As of June 2014, Antero had over 9 trillion cubic feet of proved reserves and 37.5 trillion cubic feet of potential reserves across its acreage, with production of over 1 billion cubic feet per day.
- Antero has significant growth plans through 2022 involving increasing production, reserves, and secured transportation and processing for its natural gas and natural gas liquids.
1) The company reported first quarter 2015 results with production of 14.3 MBoe/d, a 21% increase over the previous year. Operating costs continued to improve with cash operating costs of $12.32/Boe, down 27% from the previous year.
2) The company drilled 8 and completed 13 horizontal wells in the Wolfcamp B and C zones, with average initial production of 723 Boe/d.
3) The company's water recycling facility became fully operational in March 2015 and is expected to reduce drilling and completion costs by $450k per well and lower operating expenses.
Similar to Hermosa Beach - Cost Benefit Analysis - Development Supplemental Agreement (20)
This ordinance proposes to amend the City of Hermosa Beach's Coastal Land Use Plan and municipal code to allow an oil and gas drilling and production project. It would allow E&B Natural Resources to develop 30 production wells, 4 water injection wells, and gas processing equipment on city-owned land. The ordinance outlines amendments to allow the project, approves a development agreement with E&B, and grants an oil pipeline franchise. It finds that the project was properly reviewed per CEQA and certifies the final EIR, though some environmental impacts would remain significant even with mitigation.
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2. HERMOSA BEACH - OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS [DRAFT]
Table of Contents
1.0 Executive Summary ..........................................................................................................1
2.0 Background.......................................................................................................................3
3.0 Public Benefits Provided in DA .........................................................................................5
3.1 Accelerated Uplands Royalty Payments (~Years 1-5) ...................................................5
3.2 Bonus Payments to Ensure $1,000,000 Minimum Royalty (~Years 4-13) .....................5
3.3 Remediation of City Maintenance Yard ..........................................................................6
3.4 Relocation of City Maintenance Yard .............................................................................6
3.5 Payment to City to Fund Community Improvements ......................................................7
3.6 Hermosa Beach Property Fund ......................................................................................7
3.7 Cumulative Impact on City Costs ...................................................................................7
4.0 Supplemental Exhibits.......................................................................................................9
5.0 Oil Price Sensitivity .........................................................................................................21
6.0 School Revenues ............................................................................................................24
6.1 School District Revenues .............................................................................................24
6.2 Education Foundation Revenues .................................................................................24
7.0 Conclusion ......................................................................................................................25
3. HERMOSA BEACH - OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS [DRAFT]
Index of Tables & Figures
Table 23-A: Summary of Direct City Costs (without DA) ..............................................................8
Table 23-B: Summary of Direct City Costs (DA Terms)................................................................8
Figure 1-A: Estimated Gross City Revenues, Expenses & Net Revenues ($95/BBL, without
DA, $2014)............................................................................................................10
Figure 1-B: Estimated Gross City Revenues, Expenses & Net Revenues ($95/BBL, DA
Terms, $2014).......................................................................................................10
Figure 1-C: Estimated Gross City Revenues, Expenses & Net Revenues ($40/BBL, without
DA, $2014.............................................................................................................11
Figure 1-D: Estimated Gross City Revenues, Expenses & Net Revenues ($40/BBL, DA
Terms, $2014).......................................................................................................11
Figure 1-E: Estimated Gross City Revenues, Expenses & Net Revenues ($120/BBL, without
DA, $2014)............................................................................................................12
Figure 1-F: Estimated Gross City Revenues, Expenses & Net Revenues ($120/BBL, DA
Terms, $2014).......................................................................................................12
Figure 16-A: Flowchart of City Royalty Calculations (With DA Terms) .......................................13
Figure 17-A: Calculation of City Share of Oil & Gas Production (without DA & with DA
Terms)...................................................................................................................14
Figure 43-A: Summary of Net Projected Revenues with Project ($95/BBL, without DA,
$2014)...................................................................................................................15
Figure 43-B: Summary of Net Projected Revenues with Project ($95/BBL, DA Terms, $2014).16
Figure 43-C: Summary of Net Projected Revenues with Project ($40/BBL, without DA,
$2014)...................................................................................................................17
Figure 43-D: Summary of Net Projected Revenues with Project ($40/BBL, DA Terms,
$2014)...................................................................................................................18
Figure 43-E: Summary of Net Projected Revenues with Project ($120/BBL, without DA,
$2014)...................................................................................................................19
Figure 43-F: Summary of Net Projected Revenues with Project ($120/BBL, DA Terms,
$2014)...................................................................................................................20
Figure 100: Estimated Gross and Net Projected City Revenues – Range of Oil Prices
(without DA, $2014) ..............................................................................................22
Figure 101: Estimated Gross and Net Projected City Revenues – Range of Oil Prices (DA
Terms, $2014).......................................................................................................23
Figure 102: Estimated Net School District Revenues (in millions of $2014, not impacted by
DA Terms).............................................................................................................24
Figure 103: Estimated Net School District Revenues (in millions of $2014, no change under
DA Terms).............................................................................................................24
4. HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
Notice Regarding This Development Agreement
Supplement to the CBA
This Development Agreement Supplement (“DA Supplement”) to the Cost Benefit
Analysis (“CBA”) has been prepared by Kosmont Companies and oil and gas industry
sub-consultant CGEOIL, LLC for the City of Hermosa Beach. This document was
prepared to evaluate potential economic benefits that may accrue to the City of
Hermosa Beach under the Development Agreement that may be entered into by and
between the City of Hermosa Beach and the Project Applicant should the proposed
Project be approved under Measure O.
This DA Supplement does not contain a comprehensive evaluation of the proposed
Project, but rather only provides updates to analysis and estimates in the CBA pursuant
to the terms of the Development Agreement, and current oil prices. Readers are
encouraged to review the CBA released and accepted by the Hermosa Beach City
Council in September of 2014, prior to the review of this document.
For an abundance of clarity, as stated in the CBA, the Authors neither support nor
oppose the proposed Project. In the Authors' opinion, this DA Supplement and the CBA
report present a neutral and unbiased perspective of the potential costs and benefits of
the proposed Project to the City.
The CBA Team is not a law firm and does not provide legal counsel. The interpretation
of the Development Agreement by the CBA Team should not be considered legal
advice and/or conclusions of law.
For reference, as of the circulation of this document, the final CBA was available at:
http://www.hermosabch.org/modules/showdocument.aspx?documentid=4684
Additionally, the DA was available at:
http://www.hermosabch.org/modules/showdocument.aspx?documentid=5054
5. 1
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
1.0 Executive Summary
This Development Agreement Supplement to the Cost Benefit Analysis provides follow-on
analysis of the potential costs and benefits to the City of Hermosa Beach of the oil drilling and
recovery project (“Project”) proposed by E&B Natural Resources Management Corporation
(“Applicant”). The analysis in this supplement evaluates provisions of a proposed Development
Agreement (“DA”) negotiated between the City and Applicant after the final Cost Benefit
Analysis (“CBA”) was accepted by the City. The Development Agreement would be entered into
should the voters of Hermosa Beach approve the proposed Project. A discussion of estimated
City revenues and expenses should voters not approve the proposed Project is provided in the
CBA.
As discussed in the CBA, if the Project were approved the City would be entitled to royalty
revenues from oil and gas produced under the Project. Based on production estimates
completed as part of the CBA, an assumed oil price of $95 per barrel and excluding the terms of
the DA, the Authors estimated that over the 35 year life of the Project the City would realize net
revenues of approximately $118 to $270 million ($2014). Of this total, approximately $25 to $77
million (net, 21 - 29%) was estimated to accrue to the City’s Uplands Fund, which is part of the
City’s General Fund, and the balance accruing to the City’s Tideland Fund. Utilizing production
estimates from the Applicant rather than those from the CBA, the Authors estimated that the
City would realize net revenues of approximately $450 million ($2014), of which it was estimated
that $139 million (net, 31%) would accrue to the City’s General Fund.
As evaluated herein, under the proposed DA, and based on the same assumed oil price of $95
per barrel, the Authors estimate that over the 35 year life of the proposed Project the City would
realize net revenues of approximately $138 to $301 million ($2014). Of this total, approximately
$46 to $109 million (net, 33 - 36%) is estimated to accrue to the City’s General Fund, and the
balance to the City’s Tideland Fund. Utilizing production estimates from the Applicant rather
than those from the CBA, the Authors estimate that the City would realize net revenues of
approximately $494 million ($2014), of which it is estimated that $184 million (net, 37%) would
accrue to the City’s General Fund. Thus, the various public benefit provisions of the DA
notably increase the estimated revenues that would be expected to accrue to the City under the
proposed Project, and also serve to provide a greater share of overall revenues to the Uplands
fund.
Subsequent to the City’s acceptance of the CBA, and prior to the drafting of this DA Supplement
the price of oil dropped substantially from roughly $90 to $100 per barrel of California Midway
Sunset crude to just above $40 per barrel ($41.77 posted by Chevron as of January 21, 2015).
Given the City’s royalty structures, the figures estimated above could decrease substantially
should current pricing be indicative of a long term trend. To assist the reader in evaluating the
potential magnitude of impacts to City revenues assuming a variety of oil prices, figures
illustrating City revenues under oil prices ranging from $40 to 120 per barrel are provided
herein.
6. 2
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
With respect to potential revenues for the Hermosa Beach City School District, based on
production estimates completed as part of the CBA and based on oil pricing of $95 per barrel,
the Authors estimated that the School District would receive net revenues of approximately $1.2
to $2.2 million ($2014) over the life of the Project, or, assuming the production estimates from
the Applicant, $3.8 million ($2014). These estimates would not change under the terms of the
DA, but would change should current oil prices be representative of a long term trend.
Estimates of School District revenues assuming oil prices ranging from $40 to $120 per barrel
are also provided herein.
Further, under the ballot language and ordinance for the Project, the Applicant has stated that it
has assigned a 1% overriding royalty to the Hermosa Beach Education Foundation. Based on
an oil price of $95 per barrel, the Authors estimate that the Education Foundation would receive
net revenues of approximately $10.5 to $21.4 million ($2014) over the life of the Project, or,
assuming the production estimates from the Applicant, $34.3 million ($2014). Again however,
these estimates would change should current oil prices be representative of a long term trend.
Estimates of Education Foundation revenues assuming oil prices ranging from $40 to $120 per
barrel are included in this supplement.
7. 3
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
2.0 Background
As previously introduced, the City of Hermosa Beach is in the process of evaluating a proposal
by the Applicant to develop the Project within the City. As part of the City's evaluation, the City
retained Kosmont Companies ("Kosmont") and sub-consultant CGEOIL, LLC (collectively
"Kosmont Team", or "Authors") to prepare the Cost Benefit Analysis (“CBA”) to evaluate the
potential financial costs and benefits to the City of the proposed Project. Subsequent to the
release of the final CBA in September of 2014, the City and Applicant completed negotiations
on a proposed Development Agreement (“DA”). This supplemental report to the CBA (“DA
Supplement”) considers terms of the DA that pertain to the analysis in the CBA, and provides
supplemental analysis as appropriate. Additionally, this DA supplement includes a discussion
and analysis of estimated gross and net City revenues given changes in the price of oil.
Readers are encouraged to review the final CBA released in September of 2014 prior to the
review of this document. The City has also prepared and made available its summary of the
terms and provisions of the DA. Additional information pertinent to the review of this DA
Supplement follows below.
Production Estimates
This DA Supplement estimates City and Hermosa Beach Education Foundation (“Education
Foundation”) revenues based on the oil and gas production estimates evaluated in the CBA
(please see Section 5.0 beginning on page 20 of the CBA). These estimates are classified as
“CBA Low” (~10.9 million barrels), “CBA Expected” (~17.1 million barrels), “CBA High” (~22.2
million barrels), and “Applicant” (~35.6 million barrels) and represent different estimates of oil
(and gas) that might be produced over the life of the Project should it be approved.
Oil Price Points
Revenue estimates in the CBA were calculated assuming a fixed price of $95 per barrel ($2014,
plus inflation in future years) of California Midway Sunset (“CMS”). This assumed price was in
line with oil prices at the time of the drafting of the CBA (please see Section 6.0 beginning on
page 32 of the CBA). However, subsequent to the publication of the CBA, and as of the drafting
of this DA Supplement, the price of oil has dramatically decreased. As of January 21, 2015
Chevron’s posted price for CMS was $41.77 per barrel. Given the currently significant
difference in oil pricing, this DA Supplement includes analysis of City revenues given various
price points. The three primary price scenarios evaluated herein are a low assumed price of
$40 per barrel, the CBA assumed price of $95 per barrel, and a high assumed price of $120 per
barrel. Estimated revenues under oil price increments between $40 and $120 per barrel are
also provided in Figure 100 and Figure 101 on pages 22 and 23.
Note Regarding Oil Prices Evaluated: The range of oil prices evaluated herein ($40 to
$120 per barrel of CMS) are for reference only, and do not represent predictions of future
8. 4
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
oil prices. It is the Authors opinion that should oil prices remain below approximately
$60 per barrel of CMS over the long term, there may not be sufficient revenues to justify
all of the substantial costs of Project infrastructure (i.e. production wells) required to
realize the potential production volumes estimated in the CBA (i.e. CBA Low, CBA
Expected, and CBA High). Further, the Authors expect that the Applicant may not
proceed with the Project should oil prices remain at their current levels ($2014) over the
life of the Oil Lease. However, it is the Authors opinion that it is unlikely that oil prices
will remain at their current levels for an extended period of time, and likely that prices will
return to levels above $60 per barrel in the future, though as discussed in Section 6.0 of
the CBA (beginning on page 32 of the CBA) accurately predicting long term oil pricing is
elusive.
Rounding Errors
In both the CBA and this document figures are often rounded to differing levels of significant
digits for ease of reading. When rounded sums are added they may not equal the rounded sum
of the unrounded values. Calculations herein are based on unrounded values from the same
data sets, but results of calculations are often presented as rounded values that may not
precisely match based on differing levels of rounding (i.e. rounded to the nearest thousand
versus to the nearest ten-thousand).
Present Values
Figures in this DA Supplement are presented on a present value basis (please see Section 2.5
beginning on page 7 of the CBA) in 2014 dollars (“$2014”) unless otherwise noted.
Numbering of Tables & Figures
Many of the figures in this DA Supplement are duplicates and/or iterations of figures contained
in the final CBA. Duplicates are provided for easy reference. Iterations are provided to illustrate
the impact of DA terms on estimates, and/or additional analysis based on alternative
assumptions on future oil prices. Where figures represent duplicates and/or iterations, the
original figure number from the CBA is preserved, and a hyphen and alphabetical letter are
added (i.e. Figure 1-A). New tables and figures that are not duplicates and/or iterations of CBA
exhibits are denoted by a number at or above 100 (i.e. Figure 100).
9. 5
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
3.0 Public Benefits Provided in DA
Should the Project be approved, and the proposed Development Agreement goes into effect,
the Applicant would provide a number of benefits to the City in addition to those provided for
under the Oil Lease and Settlement Agreement. A discussion of relevant DA provisions follows
in this Section. Further, analysis of the cumulative impact of these provisions on City revenue
calculations is provided in Figures 1-A through 1-F and Figures 43-A through 43-F in Section
4.0.
3.1 Accelerated Uplands Royalty Payments (~Years 1-5)
Pursuant to Paragraph 1 of Exhibit C to the DA, generally, the Applicant will ensure that the City
receives a minimum of $1 million in Project related gross annual Uplands revenues for five
years commencing upon the City’s issuance to the Applicant of a permit for the first well. To the
extent that annual Uplands revenues due to the City are less than $1 million during the five year
period, the Applicant shall pay the City (backfill) the difference between actual annual Uplands
revenues and $1 million. Any such payment by the Applicant shall be considered an
accelerated Uplands royalty payment, and be repaid with future revenues earned after the five
year period, subordinate to / net of the repayment of advances (discussed in Section 9.5
beginning on page 59 of the CBA). To the extent that future Uplands royalty revenues are not
sufficient to repay the accelerated payments, such portion of accelerated payments would be
forgiven.
Based on the scenarios evaluated herein, this provision is estimated to have a modest positive
impact on the overall present value of the proposed Project to the City. While the provision
certainly would provide the City revenue immediately upon issuance of a well permit, such funds
would directly offset subsequent revenues until repaid. Based on the four production estimates
and three oil price points evaluated herein, this provision represents a positive present value to
the City of between approximately $0 to $220,000 ($2014), with higher present values generally
ascribed to lower oil prices and lower or intermittent production.
3.2 Bonus Payments to Ensure $1,000,000 Minimum Royalty (~Years 4-13)
Pursuant to Paragraph 2 of Exhibit C to the DA, generally, the Applicant will ensure that the City
receives a minimum of $1 million in Project related gross annual revenues between the
Tidelands and Uplands funds during roughly years four through 13 of the proposed Project.
Under the Lease the City is currently entitled to receive a minimum of $500,000 per year
commencing the fourth year after completion of the first well (please see Section 7.5 beginning
on page 48 of the CBA). This provision of the DA would effectively increase the minimum from
$500,000 to $1 million per year, commencing four years from the completion of the first well
through the 13th
anniversary of the completion of the first well. Thus, under this provision of the
DA, should actual combined City Tidelands and Uplands revenues be less than $1 million
during the applicable years, the Applicant will pay to the City the difference between $1 million
10. 6
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
and actual revenues. It is the Authors conclusion that any such minimum lease or bonus
payment would effectively go to the Uplands and not be subject to Tidelands restrictions.
Based on the scenarios evaluated herein, this provision is estimated to have no impact on the
overall present value of the proposed Project to the City. While the provision certainly would
provide the City revenues if there were no or limited oil production, none of the four production
estimates and three oil price points evaluated herein resulted in a payment being made to the
City under this provision.
3.3 Remediation of City Maintenance Yard
Pursuant to Paragraph 3 of Exhibit C to the DA, generally, should the Applicant proceed with
Phase 3 of the proposed Project (please see Section 2.6 beginning on page 9 of the CBA), then
the Applicant would pay for the environmental remediation of the existing City maintenance yard
(“Project Site”). The estimated cost of remediating the Project Site is approximately $3.8 million
($2014). Without this provision in the DA, if the proposed Project were approved, substantially
all of this cost would have been borne by the City. As such this provision of the DA provides a
benefit to the City of approximately $3.8 million ($2014) before potential financing
considerations.
3.4 Relocation of City Maintenance Yard
Pursuant to Paragraph 4 of Exhibit C to the DA, generally, upon issuance by the City to the
Applicant of a drilling permit for the first well, the City shall not be required to repay the $3.5
million settlement payment required under Section 4.6.b of the Settlement Agreement. Note:
The DA reads “Section 4.6.b of the Lease” though the Authors conclude this was intended to
refer to the Settlement Agreement. In addition, the DA provides that should the Applicant
proceed with Phase 3 of the proposed Project then the Applicant shall provide an advance of
$6.5 million to the City to fund the permanent relocation of the City maintenance yard. Note:
The Authors interpret this provision and advance to be an increase in the “Advance” provided
for under Section 13.d of the Oil Lease from $500,000 to $6.5 million.
Based on the four production estimates and three oil price points evaluated herein, the
forgiveness of the $3.5 million settlement payment represents a present value to the City of
approximately $2.9 to $3.1 million ($2014). The estimated present value is less than $3.5
million as repayment of the settlement payment is limited by maximum annual payments that
serve to extend full repayment several years into the future, without interest, resulting in a lower
present value.
With respect to the $6.5 million advance, repayment provisions are defined under the terms of
the Oil Lease (please see Section 9.5 beginning on page 59 of the CBA), and notably, include a
simple interest formula rather than a compounding formula. The effect on projected City
cashflows is a reduction in the amount of money that may need to be externally financed, as
well as a reduction in estimated financing costs. Thus, while the $6.5 million advance needs to
be repaid, borrowing the money as an advance has a lower present value than the alternatives
11. 7
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
evaluated. Based on the four production estimates and three oil price points evaluated herein,
this provision represents a positive present value to the City of between approximately $2.4 to
$2.6 million ($2014), with higher values generally ascribed to higher oil prices and production
estimates (and faster repayment).
3.5 Payment to City to Fund Community Improvements
Pursuant to Paragraph 5 of Exhibit C to the DA, generally, the Applicant will pay to the City an
additional amount equal to 1% of gross oil and gas production revenues. Further, the Applicant
will provide an initial accelerated payment of $1 million upon the City’s issuance of a drilling
permit for the first well. It is the Authors understanding that this $1 million payment shall be an
offset to / repaid with future revenues. Based on the four production estimates and three oil
price points evaluated herein, this provision represents a positive present value to the City of
between approximately $4.6 to $43.3 million ($2014), with higher values ascribed to higher oil
prices and production estimates.
3.6 Hermosa Beach Property Fund
Pursuant to Paragraph 6 of Exhibit C to the DA, generally, the Applicant shall set up a fund to
compensate owners of property within 600 feet of the proposed Project in the event that they
sell their property and the sales price is impaired due to the Project. The reader is encouraged
to review Paragraph 6 of Exhibit C for further details of this provision. The focus of the CBA and
this DA Supplement is the quantification of potential Project costs and benefits primarily from
the perspective of the City as a municipal organization, and not individual property owners. As
such, the Authors did not attempt to quantify this as an offset to potential costs.
3.7 Cumulative Impact on City Costs
In Section 9.10 of the CBA (page 69) a summary of estimated direct City Costs are provided in
Table 23. The provisions of the DA discussed above serve to reduce the total estimated net
direct City costs provided therein from approximately $26.7 to $19.4 million ($2014, before
financing considerations). A duplication of Table 23 from the CBA is provided below in Table
23-A, and the same summary, updated to reflect the terms of the DA also follows in Table 23-B.
12. 8
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
Table 23-A: Summary of Direct City Costs (without DA)
Table 23-B: Summary of Direct City Costs (DA Terms)
Note: These costs in Error! Reference source not found.-A and 23-B above do not include the
potential cost of financing, or the use of advances pursuant to the Oil Lease. These additional
considerations are evaluated and summarized in Figures 43-A through 43-F in Section 4.0
below.
$2014 Offset Net Cost Notes
Settlement Payment 3,500,000$ none 3,500,000$ Paid through royalty revenues
Temporary Maintenance Yard 3,050,000 none 3,050,000
Permanent Maintenance Yard 9,990,000 none 9,990,000 Superior to existing facility
Loss of storage Site Revenue 6,390,000 none 6,390,000 Average of estimated value range
Maintenance Yard Remediation 3,810,000 50,000$ 3,760,000 $50k to be paid by Applicant
Emergency Trust Fund 2,000,000 100% - Funds are returned if not used
Fire Service 16,490,000 100% - Cost required to be paid by Applicant
Ongoing Project Monitoring 11,900,000 100% - Recouped through Well Permit Fee
57,130,000$ 26,690,000$
$2014 Offset Net Cost Notes
Settlement Payment 3,500,000$ 100% -$ Forgiven upon issuance of drilling permit
Temporary Maintenance Yard 3,050,000 none 3,050,000
Permanent Maintenance Yard 9,990,000 none 9,990,000 Superior to existing facility
Loss of storage Site Revenue 6,390,000 none 6,390,000 Average of estimated value range
Maintenance Yard Remediation 3,810,000 100% - Cost paid by Applicant
Emergency Trust Fund 2,000,000 100% - Funds are returned if not used
Fire Service 16,490,000 100% - Cost required to be paid by Applicant
Ongoing Project Monitoring 11,900,000 100% - Recouped through Well Permit Fee
57,130,000$ 19,430,000$
13. 9
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
4.0 Supplemental Exhibits
In this Section, exhibits from the CBA, and iterations thereof based on different assumptions are
provided as follows:
Iterations of Figure 1 and Figure 43 from the CBA illustrating estimated costs and
revenues (i) with or without inclusion of the terms of the proposed DA, and (ii) assuming
an oil price of $95 per barrel (“BBL”), $40 per barrel, and $120 per barrel.
Iterations of Figure 16 and Figure 17 from the CBA illustrating modifications only in
consideration of the terms in the proposed DA.
Figures 1, 16, 17, and 43 from the CBA and iterations thereof follow below.
14. 10
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
Figure 2-A: Estimated Gross City Revenues, Expenses & Net Revenues ($95/BBL, without DA, $2014)
Figure 1-B: Estimated Gross City Revenues, Expenses & Net Revenues ($95/BBL, DA Terms, $2014)
96.0 M 93.5 M
150.7 M 148.2 M
195.5 M 193.1 M
313.6 M 311.1 M
50.7 M
24.5 M
79.6 M
53.4 M
103.2 M
77.1 M
165.6 M
139.4 M
2.5 M 2.5 M 2.5 M 2.5 M
26.2 M 26.2 M 26.2 M 26.2 M
146.7 M
28.7 M
118.0 M
230.2 M
28.6 M
201.6 M
298.8 M
28.7 M
270.1 M
479.2 M
28.7 M
450.4 M
$ M
$ 100 M
$ 200 M
$ 300 M
$ 400 M
$ 500 M
$ 600 M
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Tidelands Uplands Tidelands Expenses Uplands Expenses
96.0 M 92.2 M
150.7 M 146.9 M
195.5 M 191.8 M
313.6 M 309.8 M
61.3 M
45.7 M
96.1 M
80.5 M
124.7 M
109.1 M
200.0 M
184.4 M
3.8 M 3.8 M 3.8 M 3.8 M
15.6 M 15.6 M 15.6 M 15.6 M
157.3 M
19.4 M
137.9 M
246.8 M
19.3 M
227.4 M
320.2 M
19.3 M
300.9 M
513.6 M
19.4 M
494.2 M
$ M
$ 100 M
$ 200 M
$ 300 M
$ 400 M
$ 500 M
$ 600 M
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Tidelands Uplands Tidelands Expenses Uplands Expenses
CBA Low CBA Expected CBA High Applicant
CBA Low CBA Expected CBA High Applicant
15. 11
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
Figure 1-C: Estimated Gross City Revenues, Expenses & Net Revenues ($40/BBL, without DA, $2014)
Figure 1-D: Estimated Gross City Revenues, Expenses & Net Revenues ($40/BBL, DA Terms, $2014)
41.2 M 38.5 M
64.7 M 62.0 M
83.9 M 81.3 M
134.6 M 132.1 M
21.8 M
34.2 M
8.0 M
44.3 M
18.2 M
71.1 M
44.9 M
2.7 M 2.7 M 2.6 M 2.5 M
26.2 M 26.1 M 26.1 M 26.2 M
63.0 M
28.9 M
34.1 M
98.8 M
28.8 M
70.0 M
128.3 M
28.8 M
99.5 M
205.7 M
28.7 M
177.0 M
$ M
$ 100 M
$ 200 M
$ 300 M
$ 400 M
$ 500 M
$ 600 M
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Tidelands Uplands Tidelands Expenses Uplands Expenses
41.2 M 37.2 M
64.7 M 60.7 M
83.9 M 80.0 M
134.6 M 130.8 M
26.6 M
10.9 M
41.4 M
25.7 M
53.6 M
37.9 M
86.1 M
70.5 M
4.0 M 4.0 M 4.0 M 3.9 M
15.7 M 15.7 M 15.7 M 15.6 M
67.8 M
19.8 M
48.1 M
106.0 M
19.7 M
86.3 M
137.6 M
19.7 M
117.9 M
220.8 M
19.5 M
201.3 M
$ M
$ 100 M
$ 200 M
$ 300 M
$ 400 M
$ 500 M
$ 600 M
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Tidelands Uplands Tidelands Expenses Uplands Expenses
CBA Low CBA Expected CBA High Applicant
CBA Low CBA Expected CBA High Applicant
-4.4 M
Note to Figures 1-C and 1-D: Please see the Note Regarding Oil Prices Evaluated beginning on page 3.
16. 12
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
Figure 1-E: Estimated Gross City Revenues, Expenses & Net Revenues ($120/BBL, without DA, $2014)
Figure 1-F: Estimated Gross City Revenues, Expenses & Net Revenues ($120/BBL, DA Terms, $2014)
120.9 M 118.5 M
189.7 M 187.3 M
246.2 M 243.8 M
394.9 M 392.4 M
63.8 M
37.7 M
100.2 M
74.0 M
130.0 M
103.8 M
208.5 M
182.3 M
2.4 M 2.4 M 2.4 M 2.5 M
26.2 M 26.2 M 26.2 M 26.2 M
184.7 M
28.6 M
156.1 M
289.9 M
28.6 M
261.3 M
376.2 M
28.6 M
347.6 M
603.4 M
28.7 M
574.7 M
$ M
$ 100 M
$ 200 M
$ 300 M
$ 400 M
$ 500 M
$ 600 M
$ 700 M
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Tidelands Uplands Tidelands Expenses Uplands Expenses
120.9 M 117.2 M
189.7 M 186.0 M
246.2 M 242.5 M
394.9 M 391.1 M
77.2 M
61.6 M
121.0 M
105.5 M
157.1 M
141.5 M
251.9 M
236.3 M
3.7 M 3.7 M 3.7 M 3.8 M
15.6 M 15.6 M 15.6 M 15.6 M
198.1 M
19.3 M
178.8 M
310.8 M
19.3 M
291.5 M
403.3 M
19.3 M
384.0 M
646.8 M
19.4 M
627.4 M
$ M
$ 100 M
$ 200 M
$ 300 M
$ 400 M
$ 500 M
$ 600 M
$ 700 M
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Gross
Revenues
Expenses
Net
Revenues
Tidelands Uplands Tidelands Expenses Uplands Expenses
CBA Low CBA Expected CBA High Applicant
CBA Low CBA Expected CBA High Applicant
17. 13
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
Figure 16-A: Flowchart of City Royalty Calculations (With DA Terms)
Note to Figure 16-A: Changes to this figure to reflect terms in the DA are identified by the gray dotted box
18. 14
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
(withoutDA)
CityRevenueCalculations
Forevery
$100
Produced
ForEvery
$100inCity
Revenues
ForEvery$100Produced
ProducedfromTidelands78.28%ProducedinTidelands($100x78.28%)78.28$
ProducedfromUplands21.72%ProducedinUplands($100x21.72%)21.72
City-Tidelands
CityTidelandsRoyalty18.67%ofallOil&GasProducedinTidelands($100x78.28%x18.67%)14.61$104.71
Less:DrillSiteLeasePaymenttoUplands-37.50%ofCityTidelandsRoyalty-($100x78.28%x18.67%x37.50%)(5.48)(39.27)
SubtotalCityTidelands9.13$65.44$
City-Uplands
CityShare/CityLandOwnership23.83%
CityUplandsRoyalty11.67%ofCityShareofOil&GasProducedinUplands($100x21.72%x23.83%x11.67%)0.604.33
DrillSiteLease-UplandsPayment7.00%ofallOil&GasProducedinUplands($100x21.72%x7.00%)1.5210.90
DrillSiteLease-TidelandsPayment37.50%ofCityTidelandsRoyalty($100x78.28%x18.67%x37.50%)5.4839.27
Less:RoyaltytoMacphersonOilCompany-3.33%ofCityShareofOil&GasProduced-($100x78.28%x3.33%)-($100x21.72%x23.83%x3.33%)(2.78)(19.93)
SubtotalCityUplands4.82$34.56$
TotalCityRevenue13.95$100.00$
(DATerms)
CityRevenueCalculations
Forevery
$100
Produced
ForEvery
$100inCity
Revenues
ForEvery$100Produced
ProducedfromTidelands78.28%ProducedinTidelands($100x78.28%)78.28$
ProducedfromUplands21.72%ProducedinUplands($100x21.72%)21.72
City-Tidelands
CityTidelandsRoyalty18.67%ofallOil&GasProducedinTidelands($100x78.28%x18.67%)14.61$97.71
Less:DrillSiteLeasePaymenttoUplands-37.50%ofCityTidelandsRoyalty-($100x78.28%x18.67%x37.50%)(5.48)(36.64)
SubtotalCityTidelands9.13$61.07$
City-Uplands
CityShare/CityLandOwnership23.83%
CityUplandsRoyalty11.67%ofCityShareofOil&GasProducedinUplands($100x21.72%x23.83%x11.67%)0.604.04
DrillSiteLease-UplandsPayment7.00%ofallOil&GasProducedinUplands($100x21.72%x7.00%)1.5210.17
DrillSiteLease-TidelandsPayment37.50%ofCityTidelandsRoyalty($100x78.28%x18.67%x37.50%)5.4836.64
Less:RoyaltytoMacphersonOilCompany-3.33%ofCityShareofOil&GasProduced-($100x78.28%x3.33%)-($100x21.72%x23.83%x3.33%)(2.78)(18.60)
1%CommunityImprovementFund1.00%ofallOil&GasProduction($100x1.00%)1.006.69
SubtotalCityUplands5.82$38.93$
TotalCityRevenue14.95$100.00$
Figure 17-A: Calculation of City Share of Oil & Gas Production (without DA & with DA Terms)
19. 15
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
Figure 43-A: Summary of Net Projected Revenues with Project ($95/BBL, without DA, $2014)
Low High
CBA Low CBA Expected CBA High Applicant
Tidelands Royalties
Gross Tidelands Oil & Gas Revenues 96,000,000$ 150,650,000$ 195,510,000$ 313,570,000$
Less: Settlement Agreement Payment - - - -
Less: Repayment of Advances (70% of Repayment) (3,030,000) (3,030,000) (3,030,000) (3,100,000)
Less: Allocation for Emergency Trust (70% of Funding) 540,000 560,000 570,000 600,000
Net Tidelands Revenues 93,520,000$ 148,190,000$ 193,050,000$ 311,070,000$
Uplands Royalties
Gross Uplands Oil & Gas Revenues 50,690,000$ 79,550,000$ 103,240,000$ 165,580,000$
Less: Settlement Agreement Payment (3,100,000) (3,100,000) (3,100,000) (3,120,000)
Less: Repayment of Advances (30% of Repayment) (1,300,000) (1,300,000) (1,300,000) (1,330,000)
Less: Allocation for Emergency Trust (30% of Funding) 230,000 240,000 240,000 260,000
Net Uplands Royalty Revenues 46,530,000$ 75,390,000$ 99,080,000$ 161,390,000$
Other Revenues & Costs (Considered Uplands)
Accelerated Uplands Royalty (Pursuant to DA) -$ -$ -$ -$
Bonus Payments (Pursuant to DA) - - - -
1% Community Improvement Fund (Pursuant to DA) - - - -
Use of City Reserve for Temporary Relocation (2,960,000) (2,960,000) (2,960,000) (2,960,000)
Use of City Reserve for Project Site Remediation (50,000) (50,000) (50,000) (50,000)
Use of City Reserve for Permanent Relocation (2,660,000) (2,660,000) (2,660,000) (2,660,000)
Debt Service For Permanent Relocation (Approximate) (9,980,000) (9,980,000) (9,980,000) (9,980,000)
Loss of Storage Site Revenues (6,390,000) (6,390,000) (6,390,000) (6,390,000)
Total Other Revenues & Costs (22,030,000)$ (22,030,000)$ (22,030,000)$ (22,030,000)$
Net Uplands Revenues After Other Costs 24,500,000$ 53,370,000$ 77,050,000$ 139,360,000$
Net Tidelands & Uplands Revenues 118,020,000$ 201,550,000$ 270,100,000$ 450,430,000$
20. 16
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
Figure 43-B: Summary of Net Projected Revenues with Project ($95/BBL, DA Terms, $2014)
Low High
CBA Low CBA Expected CBA High Applicant
Tidelands Royalties
Gross Tidelands Oil & Gas Revenues 96,000,000$ 150,650,000$ 195,510,000$ 313,570,000$
Less: Settlement Agreement Payment - - - -
Less: Repayment of Advances (70% of Repayment) (4,310,000) (4,310,000) (4,310,000) (4,390,000)
Less: Allocation for Emergency Trust (70% of Funding) 540,000 560,000 570,000 600,000
Net Tidelands Revenues 92,230,000$ 146,900,000$ 191,760,000$ 309,780,000$
Uplands Royalties
Gross Uplands Oil & Gas Revenues 50,690,000$ 79,550,000$ 103,240,000$ 165,580,000$
Less: Settlement Agreement Payment - - - -
Less: Repayment of Advances (30% of Repayment) (1,850,000) (1,850,000) (1,850,000) (1,880,000)
Less: Allocation for Emergency Trust (30% of Funding) 230,000 240,000 240,000 260,000
Net Uplands Royalty Revenues 49,080,000$ 77,940,000$ 101,630,000$ 163,960,000$
Other Revenues & Costs (Considered Uplands)
Accelerated Uplands Royalty (Pursuant to DA) 10,000$ 10,000$ 10,000$ 30,000$
Bonus Payments (Pursuant to DA) - - - -
1% Community Improvement Fund (Pursuant to DA) 10,580,000 16,560,000 21,470,000 34,410,000
Use of City Reserve for Temporary Relocation (2,960,000) (2,960,000) (2,960,000) (2,960,000)
Use of City Reserve for Project Site Remediation - - - -
Use of City Reserve for Permanent Relocation (2,700,000) (2,700,000) (2,700,000) (2,700,000)
Debt Service For Permanent Relocation (Approximate) (1,940,000) (1,940,000) (1,940,000) (1,940,000)
Loss of Storage Site Revenues (6,390,000) (6,390,000) (6,390,000) (6,390,000)
Total Other Revenues & Costs (3,400,000)$ 2,590,000$ 7,500,000$ 20,440,000$
Net Uplands Revenues After Other Costs 45,680,000$ 80,530,000$ 109,130,000$ 184,400,000$
Net Tidelands & Uplands Revenues 137,910,000$ 227,430,000$ 300,890,000$ 494,180,000$
21. 17
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
Figure 43-C: Summary of Net Projected Revenues with Project ($40/BBL, without DA, $2014)
Note to Figures 43-C: Please see the Note Regarding Oil Prices Evaluated beginning on page 3.
Low High
CBA Low CBA Expected CBA High Applicant
Tidelands Royalties
Gross Tidelands Oil & Gas Revenues 41,220,000$ 64,680,000$ 83,940,000$ 134,630,000$
Less: Settlement Agreement Payment - - - -
Less: Repayment of Advances (70% of Repayment) (3,100,000) (3,090,000) (3,090,000) (3,100,000)
Less: Allocation for Emergency Trust (70% of Funding) 390,000 430,000 460,000 590,000
Net Tidelands Revenues 38,510,000$ 62,020,000$ 81,310,000$ 132,110,000$
Uplands Royalties
Gross Uplands Oil & Gas Revenues 21,770,000$ 34,160,000$ 44,320,000$ 71,090,000$
Less: Settlement Agreement Payment (2,960,000) (2,970,000) (2,980,000) (3,060,000)
Less: Repayment of Advances (30% of Repayment) (1,330,000) (1,330,000) (1,330,000) (1,330,000)
Less: Allocation for Emergency Trust (30% of Funding) 170,000 180,000 200,000 250,000
Net Uplands Royalty Revenues 17,640,000$ 30,040,000$ 40,220,000$ 66,950,000$
Other Revenues & Costs (Considered Uplands)
Accelerated Uplands Royalty (Pursuant to DA) -$ -$ -$ -$
Bonus Payments (Pursuant to DA) - - - -
1% Community Improvement Fund (Pursuant to DA) - - - -
Use of City Reserve for Temporary Relocation (2,960,000) (2,960,000) (2,960,000) (2,960,000)
Use of City Reserve for Project Site Remediation (50,000) (50,000) (50,000) (50,000)
Use of City Reserve for Permanent Relocation (2,660,000) (2,660,000) (2,660,000) (2,660,000)
Debt Service For Permanent Relocation (Approximate) (9,980,000) (9,980,000) (9,980,000) (9,980,000)
Loss of Storage Site Revenues (6,390,000) (6,390,000) (6,390,000) (6,390,000)
Total Other Revenues & Costs (22,030,000)$ (22,030,000)$ (22,030,000)$ (22,030,000)$
Net Uplands Revenues After Other Costs (4,390,000)$ 8,020,000$ 18,190,000$ 44,930,000$
Net Tidelands & Uplands Revenues 34,130,000$ 70,030,000$ 99,500,000$ 177,040,000$
22. 18
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
Figure 43-D: Summary of Net Projected Revenues with Project ($40/BBL, DA Terms, $2014)
Note to Figures 43-D: Please see the Note Regarding Oil Prices Evaluated beginning on page 3.
Low High
CBA Low CBA Expected CBA High Applicant
Tidelands Royalties
Gross Tidelands Oil & Gas Revenues 41,220,000$ 64,680,000$ 83,940,000$ 134,630,000$
Less: Settlement Agreement Payment - - - -
Less: Repayment of Advances (70% of Repayment) (4,440,000) (4,440,000) (4,440,000) (4,440,000)
Less: Allocation for Emergency Trust (70% of Funding) 410,000 450,000 480,000 590,000
Net Tidelands Revenues 37,190,000$ 60,690,000$ 79,980,000$ 130,780,000$
Uplands Royalties
Gross Uplands Oil & Gas Revenues 21,770,000$ 34,160,000$ 44,320,000$ 71,090,000$
Less: Settlement Agreement Payment - - - -
Less: Repayment of Advances (30% of Repayment) (1,900,000) (1,900,000) (1,900,000) (1,900,000)
Less: Allocation for Emergency Trust (30% of Funding) 180,000 190,000 200,000 250,000
Net Uplands Royalty Revenues 20,040,000$ 32,450,000$ 42,630,000$ 69,440,000$
Other Revenues & Costs (Considered Uplands)
Accelerated Uplands Royalty (Pursuant to DA) 220,000$ 30,000$ 30,000$ 210,000$
Bonus Payments (Pursuant to DA) - - - -
1% Community Improvement Fund (Pursuant to DA) 4,600,000 7,170,000 9,280,000 14,820,000
Use of City Reserve for Temporary Relocation (2,960,000) (2,960,000) (2,960,000) (2,960,000)
Use of City Reserve for Project Site Remediation - - - -
Use of City Reserve for Permanent Relocation (2,700,000) (2,700,000) (2,700,000) (2,700,000)
Debt Service For Permanent Relocation (Approximate) (1,940,000) (1,940,000) (1,940,000) (1,940,000)
Loss of Storage Site Revenues (6,390,000) (6,390,000) (6,390,000) (6,390,000)
Total Other Revenues & Costs (9,170,000)$ (6,790,000)$ (4,680,000)$ 1,050,000$
Net Uplands Revenues After Other Costs 10,870,000$ 25,650,000$ 37,940,000$ 70,490,000$
Net Tidelands & Uplands Revenues 48,060,000$ 86,350,000$ 117,920,000$ 201,270,000$
23. 19
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
Figure 43-E: Summary of Net Projected Revenues with Project ($120/BBL, without DA, $2014)
Low High
CBA Low CBA Expected CBA High Applicant
Tidelands Royalties
Gross Tidelands Oil & Gas Revenues 120,900,000$ 189,730,000$ 246,220,000$ 394,910,000$
Less: Settlement Agreement Payment - - - -
Less: Repayment of Advances (70% of Repayment) (3,010,000) (3,010,000) (3,000,000) (3,100,000)
Less: Allocation for Emergency Trust (70% of Funding) 570,000 570,000 580,000 600,000
Net Tidelands Revenues 118,460,000$ 187,290,000$ 243,800,000$ 392,400,000$
Uplands Royalties
Gross Uplands Oil & Gas Revenues 63,840,000$ 100,190,000$ 130,020,000$ 208,530,000$
Less: Settlement Agreement Payment (3,120,000) (3,120,000) (3,120,000) (3,140,000)
Less: Repayment of Advances (30% of Repayment) (1,290,000) (1,290,000) (1,290,000) (1,330,000)
Less: Allocation for Emergency Trust (30% of Funding) 240,000 240,000 250,000 260,000
Net Uplands Royalty Revenues 59,680,000$ 96,020,000$ 125,850,000$ 204,320,000$
Other Revenues & Costs (Considered Uplands)
Accelerated Uplands Royalty (Pursuant to DA) -$ -$ -$ -$
Bonus Payments (Pursuant to DA) - - - -
1% Community Improvement Fund (Pursuant to DA) - - - -
Use of City Reserve for Temporary Relocation (2,960,000) (2,960,000) (2,960,000) (2,960,000)
Use of City Reserve for Project Site Remediation (50,000) (50,000) (50,000) (50,000)
Use of City Reserve for Permanent Relocation (2,660,000) (2,660,000) (2,660,000) (2,660,000)
Debt Service For Permanent Relocation (Approximate) (9,980,000) (9,980,000) (9,980,000) (9,980,000)
Loss of Storage Site Revenues (6,390,000) (6,390,000) (6,390,000) (6,390,000)
Total Other Revenues & Costs (22,030,000)$ (22,030,000)$ (22,030,000)$ (22,030,000)$
Net Uplands Revenues After Other Costs 37,650,000$ 73,990,000$ 103,830,000$ 182,300,000$
Net Tidelands & Uplands Revenues 156,110,000$ 261,290,000$ 347,620,000$ 574,700,000$
24. 20
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
Figure 43-F: Summary of Net Projected Revenues with Project ($120/BBL, DA Terms, $2014)
Low High
CBA Low CBA Expected CBA High Applicant
Tidelands Royalties
Gross Tidelands Oil & Gas Revenues 120,900,000$ 189,730,000$ 246,220,000$ 394,910,000$
Less: Settlement Agreement Payment - - - -
Less: Repayment of Advances (70% of Repayment) (4,290,000) (4,290,000) (4,290,000) (4,390,000)
Less: Allocation for Emergency Trust (70% of Funding) 570,000 570,000 580,000 600,000
Net Tidelands Revenues 117,180,000$ 186,010,000$ 242,510,000$ 391,120,000$
Uplands Royalties
Gross Uplands Oil & Gas Revenues 63,840,000$ 100,190,000$ 130,020,000$ 208,530,000$
Less: Settlement Agreement Payment - - - -
Less: Repayment of Advances (30% of Repayment) (1,840,000) (1,840,000) (1,840,000) (1,880,000)
Less: Allocation for Emergency Trust (30% of Funding) 240,000 240,000 250,000 260,000
Net Uplands Royalty Revenues 62,250,000$ 98,590,000$ 128,430,000$ 206,910,000$
Other Revenues & Costs (Considered Uplands)
Accelerated Uplands Royalty (Pursuant to DA) 10,000$ 10,000$ 10,000$ 30,000$
Bonus Payments (Pursuant to DA) - - - -
1% Community Improvement Fund (Pursuant to DA) 13,300,000 20,840,000 27,020,000 43,310,000
Use of City Reserve for Temporary Relocation (2,960,000) (2,960,000) (2,960,000) (2,960,000)
Use of City Reserve for Project Site Remediation - - - -
Use of City Reserve for Permanent Relocation (2,700,000) (2,700,000) (2,700,000) (2,700,000)
Debt Service For Permanent Relocation (Approximate) (1,940,000) (1,940,000) (1,940,000) (1,940,000)
Loss of Storage Site Revenues (6,390,000) (6,390,000) (6,390,000) (6,390,000)
Total Other Revenues & Costs (680,000)$ 6,860,000$ 13,040,000$ 29,350,000$
Net Uplands Revenues After Other Costs 61,570,000$ 105,450,000$ 141,470,000$ 236,250,000$
Net Tidelands & Uplands Revenues 178,740,000$ 291,450,000$ 383,980,000$ 627,370,000$
25. 21
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
5.0 Oil Price Sensitivity
As previously introduced, baseline estimates within the CBA assumed a price per barrel of CMS
of $95 ($2014, escalated at assumed inflation), based on then current oil prices. Subsequent to
City acceptance the CBA the price of oil dropped substantially. As of January 21, 2015
Chevron’s posted price for CMS was $41.77 per barrel. To assist in the evaluation of potential
gross and net City revenues under different oil price assumptions Figures 100 and 101 below
provide estimated City revenues assuming oil prices ranging from $40 to $120 per barrel of
CMS. Figure 100 provides estimated figures without the terms of the DA, while Figure 101
considers the terms of the proposed DA.
28. 24
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
6.0 School Revenues
6.1 School District Revenues
Should the proposed Project be approved, the Hermosa Beach City School District (“School
District”) is entitled to a royalty share of oil and gas produced on the portion of land that it owns
in the Uplands, as well as a $0.20 barrel tax on every barrel of oil produced at the Project Site
(please see Section 8.3 on page 55 of the CBA). Given the prior discussion on changes in oil
prices, net School District revenues assuming oil prices ranging from $40 to $120 per barrel of
CMS ($2014) were estimated and are illustrated in Figure 102 below. For reference, estimated
School District revenues do not change under the terms of the proposed DA.
Figure 102: Estimated Net School District Revenues (in millions of $2014, no change under DA Terms)
Note to Figure 102: The value assuming an oil price of $95 per barrel and CBA Expected production
estimates is “circled” as it represents the “base case” in the CBA. Additionally, please see the Note
Regarding Oil Prices Evaluated beginning on page 3.
6.2 Education Foundation Revenues
Pursuant to Section (12)(D) of the ballot measure and ordinance for the proposed Project, the
Applicant has assigned the Education Foundation a 1% overriding royalty interest in oil and gas
produced from the Project Site. Additionally, pursuant to the same language, the Applicant has
committed to providing the Education Foundation an upfront payment of $1 million in the form of
accelerated future royalty revenues. The estimated revenues that would flow to the Education
Foundation assuming oil prices ranging from $40 to $120 per barrel of CMS ($2014) follows in
Figure 103 below.
Figure 103: Estimated Net School District Revenues (in millions of $2014, DA Terms)
Note to Figure 103: The value assuming an oil price of $95 per barrel and CBA Expected production
estimates is “circled” as it represents the “base case” in the CBA. Additionally, please see the Note
Regarding Oil Prices Evaluated beginning on page 3.
(CBA Fixed = $95)
40.00$ 50.00$ 60.00$ 70.00$ 80.00$ 90.00$ 95.00$ 100.00$ 110.00$ 120.00$
CBALow 0.9$ 1.0$ 1.0$ 1.1$ 1.1$ 1.2$ 1.2$ 1.2$ 1.2$ 1.3$
CBAExpected 1.4 1.5 1.5 1.6 1.7 1.7 1.8 1.8 1.9 1.9
CBAHigh 1.8 1.8 1.9 2.0 2.1 2.2 2.2 2.3 2.4 2.5
Applicant 3.1 3.2 3.3 3.5 3.6 3.8 3.8 3.9 4.0 4.2
California Midway Sunset $ / Barrel
School District Net
Rev ($2014)
(CBA Fixed = $95)
40.00$ 50.00$ 60.00$ 70.00$ 80.00$ 90.00$ 95.00$ 100.00$ 110.00$ 120.00$
CBALow 4.5$ 5.6$ 6.7$ 7.8$ 8.9$ 10.0$ 10.5$ 11.1$ 12.1$ 13.2$
CBAExpected 7.1 8.8 10.5 12.2 13.9 15.6 16.5 17.4 19.1 20.8
CBAHigh 9.2 11.4 13.6 15.9 18.1 20.3 21.4 22.5 24.7 27.0
Applicant 14.7 18.3 21.9 25.4 29.0 32.6 34.3 36.1 39.7 43.2
California Midway Sunset $ / Barrel
Ed Foundation Net
Rev ($2014)
29. 25
HERMOSA BEACH – DA SUPPLEMENT TO THE OIL DRILLING & RECOVERY COST BENEFIT ANALYSIS
7.0 Conclusion
In conclusion, the Authors estimate that should the proposed Project be approved, the various
public benefit provisions of the DA notably increase the estimated revenues that would be
expected to accrue to the City, and serve to provide a greater share of overall revenues to the
Uplands fund.
Based on production estimates completed as part of the CBA, an assumed oil price of $95 per
barrel, and excluding the terms of the DA, the Authors estimated that the over the 35 year life of
the Project the City would realize net revenues of approximately $118 to $270 million ($2014).
Of this total, approximately $25 to $77 million (net, 21 - 29%) was estimated to accrue to the
City’s General Fund, and the balance to the City’s Tideland Fund. Utilizing production estimates
from the Applicant rather than those from the CBA, the Authors estimated that the City would
realize net revenues of approximately $450 million ($2014), of which it was estimated that $139
million (net, 31%) would accrue to the City’s General Fund.
As evaluated herein, under the proposed DA, revenue estimates would increase to
approximately $138 to $301 million ($2014). Of this total, approximately $46 to $109 million
(net, 33 - 36%) is estimated to accrue to the City’s General Fund, and the balance to the City’s
Tideland Fund.
Utilizing production estimates from the Applicant rather than those from this CBA, the Authors
estimate that the City would realize net revenues of approximately $494 million ($2014), of
which it is estimated that $184 million (net, 37%) would accrue to the City’s General Fund.
Subsequent to the City’s acceptance of the CBA, and prior to the drafting of this DA Supplement
the price of oil dropped substantially from roughly $90 - $100 per barrel of California Midway
Sunset crude to just above $40 per barrel ($41.77 posted by Chevron as of January 21, 2015).
Given the City’s royalty structures, the figures estimated above could decrease substantially
should current pricing be representative of a long term trend. As such readers should carefully
evaluate the alternative pricing scenarios and considerations discussed herein.